Carbon dioxide drive oil reservoir production method capable of realizing stage control on fluidity

A technology of hierarchical control and production methods, applied in the direction of production fluid, earthwork drilling and production, wellbore/well components, etc., which can solve the problems of fluid production decline, viscous fingering and channeling, and increase the difficulty of sealing gas channeling and other issues to achieve the effect of improving the mobility ratio

Active Publication Date: 2015-10-14
CHINA UNIV OF PETROLEUM (BEIJING)
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  • Summary
  • Abstract
  • Description
  • Claims
  • Application Information

AI Technical Summary

Benefits of technology

This technology uses advanced techniques like controlled hydraulic stimulation or pumping into an oil field where there are many types of rocks that have varying degrees of porosity (pores). By adjusting these parameters during drilling operations, we aim at improving the efficiency of extracting crude oil out of subterranean formations.

Problems solved by technology

This patented technical problem addressed in this patents relates to developing new methods for producing hydrocarbons from underground nonporotic oils (NPO) without causing harmful environmental impact on both producers' own interests and consumers' rights. Current techniques involve drilling multiple boreholes deep within subterranean areas, leading to potential safety hazards during operations. Therefore, research efforts aim towards finding ways to efficiently produce NPO through hydroslapping processes instead of traditional ones.

Method used

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  • Carbon dioxide drive oil reservoir production method capable of realizing stage control on fluidity
  • Carbon dioxide drive oil reservoir production method capable of realizing stage control on fluidity
  • Carbon dioxide drive oil reservoir production method capable of realizing stage control on fluidity

Examples

Experimental program
Comparison scheme
Effect test

experiment example 1

[0030] Homogeneous natural cores and heterogeneous cores with a permeability difference of 10 and 30 were selected for water flooding + CO 2 Continuous gas flooding and water flooding + water-gas alternating injection (WAG) experimental research, comparing the oil displacement effects of injection methods, and analyzing the mobility control effect of gas-water alternation. The specific operation process of the experimental example is as follows:

[0031] 1) Select cores that meet the requirements for drying, measure the length, width and height, and calculate the apparent volume.

[0032] 2) Vacuumize, saturate the formation water, and calculate the pore volume.

[0033] 3) Control the experimental temperature to the reservoir temperature of 60°C, saturate the simulated oil to irreducible water saturation, and calculate the original oil saturation.

[0034] 4) The outlet pressure was controlled at 6MPa through the back pressure valve, and the water flooding experiment was ca...

experiment example 2

[0046] Heterogeneous rock cores with a permeability difference of 30 and 100 were selected to carry out plugging experiments with small-molecule aliphatic amines respectively to study the effect of small-molecule amines on CO 2 The degree of improvement in the oil displacement effect. In this embodiment, ethylenediamine is selected as the plugging agent. Ethylenediamine (H 2 NCH 2 CH 2 NH 2 ) is a small molecular organic amine. It is a colorless and transparent viscous fluid with a pungent odor. Its melting point is 8.5°C, its boiling point is 116.5°C, and its relative density is 0.8995 at 20°C. It is soluble in water , Slightly soluble in ether. As a strong base, ethylenediamine can react with CO 2 The reaction produces ammonium carbamate, which has high viscosity and good plugging performance. The specific operation process of this experiment example is as follows:

[0047] 1) Select cores that meet the requirements for drying, measure the length, width and height, a...

experiment example 3

[0060] Heterogeneous rock cores with a permeability difference of 500 and natural rock cores with fractures were selected to carry out the sealing experiments of modified starch gel + small molecule aliphatic amine to study the effect of this measure on CO 2 The degree of improvement in the oil displacement effect. The formulation of the starch gel used in this embodiment is shown in Table 3, and the small molecule aliphatic amine used is ethylenediamine.

[0061] Table 3 modified starch gel formula

[0062]

[0063] The specific operation process of this experiment example is as follows:

[0064] 1) Select cores that meet the requirements for drying, measure the length, width and height, and calculate the apparent volume.

[0065] 2) Vacuumize, saturate the formation water, and calculate the pore volume.

[0066] 3) Control the experimental temperature to the reservoir temperature of 60°C, saturate the simulated oil to irreducible water saturation, and calculate the ori...

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Abstract

The invention relates to a carbon dioxide drive oil reservoir production method capable of realizing stage control on fluidity. The method is characterized in that for an oil reservoir formed by homogeneous cores and heterogeneous cores with the permeability ratio not exceeding 30, a water and gas alternate injection method is adopted for production; for an oil reservoir formed by heterogeneous cores with the permeability ratio in a range of 30 to 100, a carbon dioxide drive method is adopted for production; in the carbon dioxide drive process, when gas channeling occurs in a production well, small aliphatic amine molecules are used as main agents to be injected into the formation for sealing and plugging; for an oil reservoir formed by heterogeneous cores with the permeability ratio being higher than 100, the carbon dioxide drive method is adopted for production; in the carbon dioxide drive process, when the gas channeling occurs in the production well for the first time, elastic strong glue is injected into the formation for sealing and plugging; and when the gas channeling occurs in the production well again, the small aliphatic amine molecules are used as main agents to be injected into the formation for sealing and plugging.

Description

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Claims

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Application Information

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Owner CHINA UNIV OF PETROLEUM (BEIJING)
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